Experimental determination of wettability and heterogeneity effect on CO<sub>2</sub> distribution in porous media

Lv, Pengfei; Liu, Yu; Jiang, Lanlan; Song, Yongchen; Wu, Bin; Zhao, Jiafei; Zhang, Yi

doi:10.1002/ghg.1572

Cited by 20 publications

(8 citation statements)

References 25 publications

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“…CO 2 may firstly migrate into these pore spaces and finally be displaced by water during imbibition. Moreover, the glass beads used in this study was intermediate‐wet rather than water‐wet, which was different with other studies and likely resulted in different imbibition results. However, some useful information can still be extracted from the experimental results.…”

Section: Resultsmentioning

confidence: 77%

“…The corresponding properties of CO 2 were 0.28 g/mL and 0.022 cP, and 0.0018 g/mL and 0.015 cP, respectively. Based on previous works of the authors, the contact angles of the glass beads and dolomite and quartz sands in the brine‐CO 2 system were 61.75°/105.5°, 55.0°/82.0°, and 25.4°/56.6° at 40°C and 8 MPa (scCO 2 )/ambient conditions (gCO 2 ), respectively.…”

Section: Methodsmentioning

confidence: 83%

“…4 The current concept of geological CO 2 storage involves the injection of CO 2 into deep formations which typically contain brine. 5 However, heterogeneity, which has been proven to significantly affect CGS, 6,7 is encountered in an overwhelming majority of saline aquifer reservoirs, [8][9][10][11] and must thus be studied in detail. A multiphase flow in porous media depends on the inherent morphology of the pore spaces, the surface wettability, and external hydraulic forces.…”

Section: Introductionmentioning

confidence: 99%

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Pore‐scale investigation of effects of heterogeneity on CO₂ geological storage using stratified sand packs

Liu

Jiang

et al. 2017

Greenhouse Gases

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The geological sequestration of CO2 is considered to have great potential. However, the heterogeneity that characterizes most geological reservoirs significantly affects the migration, trapping, and leakage of CO2. The present study involved a pore‐scale investigation of the effects of heterogeneity in pore size and wettability using stratified sand packs. A stratified glass bead (BZ06+BZ02) pack and a quartz+dolomite pack were introduced in flow experiments at gaseous CO2 (gCO2) and supercritical CO2 (scCO2) conditions. Different injection rates, namely, 0.1, 0.3, and 0.6 mL/min, were applied to the drainage while a constant rate of 0.1 mL/min was maintained for the imbibition. High resolution CT imaging and subsequent processing of the images were used to analyze the effects of heterogeneity in pore size and wettability. The results indicate that heterogeneity in pore size and wettability alters the intrinsic percolation abilities of the individual layers of the stratified structure and weaken the linear correlation between CO2 volume and slice‐averaged porosity. It was also observed that water films sometimes exist in the layers with smaller pore spaces after drainage and it can trigger snap off events. © 2017 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Section: Resultsmentioning

confidence: 77%

Section: Methodsmentioning

confidence: 83%

Section: Introductionmentioning

confidence: 99%

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Pore‐scale investigation of effects of heterogeneity on CO₂ geological storage using stratified sand packs

Liu

Jiang

et al. 2017

Greenhouse Gases

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“…This helps to understand how CO2 will be transported during long-term storage after injection for storage and EOR. The convectively driven dissolution has been extensively studied for accelerated CO2 dissolution in saline water for CO2 storage in 2-dimensional (2-dim) Hele-Shaw experimental setups [12][13][14][15][16][17][18] and using 3-dimensional (3-dim) confined experimental setups [19][20][21][22][23][24]. An extensive review on available CO2 convective mixing experiments in water is available in Amarasinghe et al [12].…”

Section: Introductionmentioning

confidence: 99%

CO2 Convective Dissolution in Oil-Saturated Unconsolidated Porous Media at Reservoir Conditions

et al. 2021

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During CO2 storage, CO2 plume mixes with the water and oil present at the reservoir, initiated by diffusion followed by a density gradient that leads to a convective flow. Studies are available where CO2 convective mixing have been studied in water phase but limited in oil phase. This study was conducted to reach this gap, and experiments were conducted in a vertically packed 3-dimensional column with oil-saturated unconsolidated porous media at 100 bar and 50 °C (representative of reservoir pressure and temperature conditions). N-Decane and crude oil were used as oils, and glass beads as porous media. A bromothymol blue water solution-filled sapphire cell connected at the bottom of the column was used to monitor the CO2 breakthrough. With the increase of the Rayleigh number, the CO2 transport rate in n-decane was found to increase as a function of a second order polynomial. Ra number vs. dimensionless time τ had a power relationship in the form of Ra = c×τ−n. The overall pressure decay was faster in n-decane compared to crude oil for similar permeability (4 D), and the crude oil had a breakthrough time three times slower than in n-decane. The results were compared with similar experiments that have been carried out using water.

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“…The surface wettability of porous structures is of great importance in a broad range of natural and engineering applications in energy, materials, geophysics, and chemistry science, − such as oil recovery, − filtration membranes, contaminant transport and remediation, , fuel cells, , and CO 2 geo-sequestration. − Understanding the wettability of porous surfaces is a significant step toward understanding multiphase flow or migration processes, phase saturation, capillary pressure, and relative permeability variations − in these areas. However, relevant characterization of wetting phenomena in real porous media, especially on the scale of pore sizes, has not been carried out in detail …”

Section: Introductionmentioning

confidence: 99%

In Situ Local Contact Angle Measurement in a CO₂–Brine–Sand System Using Microfocused X-ray CT

Liu

Wang

et al. 2017

Langmuir

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The wettability of porous media is of major interest in a broad range of natural and engineering applications. The wettability of a fluid on a solid surface is usually evaluated by the contact angle between them. While in situ local contact angle measurements are complicated by the topology of porous media, which can make it difficult to use traditional methods, recent advances in microfocused X-ray computed tomography (micro-CT) and image processing techniques have made it possible to measure contact angles on the scale of the pore sizes in such media. However, the effects of ionic strength, CO phase, and flow pattern (drainage or imbibition) on pore-scale contact angle distribution are still not clear and have not been reported in detail in previous studies. In this study, we employed a micro-CT scanner for in situ investigation of local contact angles in a CO-brine-sand system under various conditions. The effects of ionic strength, CO phase, and flow pattern on the local contact-angle distribution were examined in detail. The results showed that the local contact angles vary over a wide range as a result of the interaction of surface contaminants, roughness, pore topology, and capillarity. The wettability of a porous surface could thus slowly weaken with increasing ionic strength, and the average contact angle could significantly increase when gaseous CO (gCO) turns into supercritical CO (scCO). Contact angle hysteresis also occurred between drainage and imbibition procedures, and the hysteresis was more significant under gCO condition.

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Experimental determination of wettability and heterogeneity effect on CO₂ distribution in porous media

Cited by 20 publications

References 25 publications

Pore‐scale investigation of effects of heterogeneity on CO₂ geological storage using stratified sand packs

Pore‐scale investigation of effects of heterogeneity on CO₂ geological storage using stratified sand packs

CO2 Convective Dissolution in Oil-Saturated Unconsolidated Porous Media at Reservoir Conditions

In Situ Local Contact Angle Measurement in a CO₂–Brine–Sand System Using Microfocused X-ray CT

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Experimental determination of wettability and heterogeneity effect on CO2 distribution in porous media

Cited by 20 publications

References 25 publications

Pore‐scale investigation of effects of heterogeneity on CO2 geological storage using stratified sand packs

Pore‐scale investigation of effects of heterogeneity on CO2 geological storage using stratified sand packs

CO2 Convective Dissolution in Oil-Saturated Unconsolidated Porous Media at Reservoir Conditions

In Situ Local Contact Angle Measurement in a CO2–Brine–Sand System Using Microfocused X-ray CT

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Experimental determination of wettability and heterogeneity effect on CO₂ distribution in porous media

Pore‐scale investigation of effects of heterogeneity on CO₂ geological storage using stratified sand packs

Pore‐scale investigation of effects of heterogeneity on CO₂ geological storage using stratified sand packs

In Situ Local Contact Angle Measurement in a CO₂–Brine–Sand System Using Microfocused X-ray CT